Liquefying and regasifying natural gases



Feb. 13, 1951 P. L. BORN ETAL 2,541,569

LIQUEFYING AND REGASIFYING NATURAL GASES Filed April 2, 1945 2 Sheets-Sheet 2 Patented Feb- 13, 1951 GASES Paul L. Born, Wilmette, and Daniel v. Meillcr, Maywood, 111.

Application April 2, 1945, Serial No. 586,250

4 Claims. 1

The present invention relates to an improved method of and apparatus for liquefying, storing and regasifying a portion of natural gas to serve as a substitute fuel during times of interruption or diminution of normal supply.

The primary purpose of the invention is to prepare a substitute fuel from natural gas during periods'when the supply of such gas is available in the gas system, and to store said substitute fuel in the liquid state until an emergency causes partial or total interruption of the normal supply, at which time the stored substitute fuel may be reasifiecl and used to replace or supplement the normal supply for the duration of the emergency.

In order that the regasified substitute fuel maysatisfactorily replace the normal supply, it must have combustion characteristics similar to those of the original natural gas, and, furthermore, the

heat input to gas burnin equipment must be satisfactory. That is to say, during any period of emergency aifecting the normal gas supply, the stored liquid, upon regasification, may be sent out or distributed essentially unmixed with the normal gas distributed, and therefore the regasified substitute fuel must have combustion or burning characteristics substantially the same as the gas normally distributed. These combustion or burning characteristics embrace such factors as (1) heating value or B. t. u. value, (2) specific gravity, and (3) rate of flame propagation. Prior methods and apparatus heretofore known to us for liquefying and regasifying natural gas have not been adequate to meet these requirements which arise in emergency situations, and more particularly for the reasons which we shall now point out.

It is commonly accepted theory, practice and fact, that to successfully liquefy natural gas on a commercial scale, it is necesary to "bleed oil or remove from the cycle the uncondensed portions of the nitrogen and other components which have lower boiling points than methane. This is because an accumulation of such constituents in the final heat exchangers would stop the liquefaction process.

Since these constituents are either non-combustible or are of low heating value, the removal of such constituents changes the calorific value, specific gravity, and combustion characteristics of the remainder. By way of illustration, assume a natural gas normally having typical characteristics substantially as follows ferred to as natural gas X) (hereinafter re- Per Cent Constituent Symbol by volume Carbon Dioririe C0 0. 0 Oxygen. 0 0. 0 Methane CH4-.-. 80. 3 "fifl-mne 5, 1 Pro axiom. 3. 7 isoutane- 0. 4 N ormal Butane 0. 9 Pen t'mn O. 1 Nitrogen N1- 9. 5

Total I 100.0

Specific gravity, dry basis (air=1.0)=0.678.

Heating (calorific) value, dry basis(30" mercury, F.) =1042 Br tish thermal units per cubic foot.

Heating (calorific) value, saturated (30" mercury, 60 F.)=1024 British thermal units per cubic foot. Heat input to a gas appl1ance=normal or If the above gas be liquefied according to a prior art process where the nitrogen and a portion of the methane are removed from the cycle, then the liquefied gas, when regasified, will have characteristics substantially as follows:

British thermal units per cubic foot.

Heating (calorific) value, saturated (3060) 1165.8 British thermal units per cubic foot.

Heat input to a gas appliance=% of normal.

Air, which may be added (as a diluent) to the above regasified liquid natural gas (X) to reduce the burner input to normal, amounts to 10.7% (by volume) of the mixture of regasified gas and air. Products of combustion or other gases may be used as a diluent in lieu of air. References to percentages for dilution of gas by 3 gas, shall hereinafter be with reference to volume percentages.

After the addition of 10.7% of air, the mixture will have characteristics substantially as follows:

Percent Analysis Symbol y volume Carbon 'D C Oxygen Oz"... Methane...

Ethann Iso- Nitrogen U H Tnfal Specific gravity of the gas-air mixture dry basis (air-l.0)=0.70l.

a t i igz zigig ri g fife, value, saturated (30'-60)=l04l.l British thermal units per cubic foot.

Heat input to a gas appliance=l00% of normal.

From the above analyses and calculated characteristics, it is obvious that this liquefied natural gas X, as put into storage, needs to be diluted with approximately 10.7% of air.

However, as the liquid gas stands in storage, a continual evaporation takes place, due to heat infiltration. The gas evaporated consists almost entirely of methane by reason of the low boiling point of methane as compared to the boiling points of the other hydrocarbons. As the methane evaporates, leaving behind the hydrocarbons of higher molecular weight, the analysis and characteristics of the stored liquid will undergo continuous change. In commercial liquefaction of natural gas, it has been the practice to store the liquid gas in containers holding approximately 50,000,000 cubic feet (measured as a gas at 30" 60) each and of such construction that the evaporation amounts to approximately 100,000 cubic feet of gas per day. The characteristics of liquefied natural gas X (when regasified) after one year in storage are shown in column (0) of accompanying Table I. In Table I, column (a) shows the volume percentage of the different constituents of a typical natural gas hereinbefore referred to as natural gas "X. Column (7)) shows the constituent percentages and other characteristics of natural gas X after this gas has been liquefied according to the aforementioned prior art process wherein N2 plus some CH4 are removed. Column (0) shows the same after one year in storage. Column (at) shows the liquefied natural gas of column (1)) plus the addition of 10.70% air. Column (e) shows the liquefied natural'gas of column (b) after one year in storage plus the addition of 24.56% air. Columns (.0 to (i) inclusive have reference to constituents, characteristics etc. of natural gas X liquefied according to the improved process herein disclosed, as will be later described.

It will be seen from this Table I that as time in storage increases, the percentage of methane decreases, the percentages of other constituents increase and the quantity of diluent required increases. This results in a very unsatisfactory condition because as shown on Table I, the diluent required upon regasification increased from approximately in the case of the freshly stored gas to approximately 25% in the case of gas stored for one year. This wide range in diluent required is undesirable because of the heavy investment in diluent compressors and because of the possibility of serious or dangerous operatiii; ing errors in the mixing of diluent and regaslfled gas particularly when changin the source of regasified gas from one storage container to another, since the characteristics of the regasified gases from the two containers may vary widely, thereby requiring widely differing amounts of diluent; furthermore mixtures of diluent and regasified liquid rich in the higher hydrocarbons, i. e. butane, propane, result in unsatisfactory performance when burnedby equipment designed for and adjusted for normal use with natural gas. To obviate the above described difiiculties and toimake the process of liquefaction, etc., practi- ,cal' for extended periods of storage, which are required for emergency'use as. contrasted with peak load usage it is necessary that the stored liquid remain essentially or substantially unchanged as the length of time in storage increases, since a change in the composition of the stored liquid changes combustion characteristics of theregasified fuel. This desired condition of having the stored liquid remain substantially unchanged as the length of time in the storage increases is made possible by storing essentially or substantially a single compound.

Our invention has as its principal method of accomplishing this objective the storage of a liquid composed almost entirely of the methane portion of the natural gas. In the preferred practice of our invention, the major portion of the hydrocarbons of higher molecular weight than ethane are first removed from the system, by condensation or absorption leaving largely methane, ethane and nitrogen in the system, following which the balance is liquefied and stored except about one-third of the nitrogen and an equal amount of methane which are vented. It will be noted by reference to accompanying Table I, columns (I) (g) (h) and (i), that the gas liquefied by our process is very high in methane content (approximately 95%) and that even after one year in storage the methane content remains in excess of By reason of this comparative stability of characteristics and high methane content, the diluent required is low and does not increase greatly with time of storage. As shown by Table I, the increment increase in diluent (in per cent) required between gas as initially stored (column b) and after one year's storage (column 0) is, in the case Of the prior art processes, three (3) times as great as the increment increase in the case of gas liquefied by our process; also the total diluent required after one year is 2 times as great for the gas liquefied by the prior art process as for gas liquefied by our process. Since the diluent required for substitute fuel liquefied by our process varies within rather narrow limits," the possibilities of serious operating errors in mixing are minimized. Where economic and operatin conditions warrant it, our process can, at the discretion of the operator, be made to yield a higher percentage of methane than is shown in Table I.

Another object of the invention is to provide an improved arrangement by which the relatively low temperatures of the removed heavier hydrocarbons (i. e. the ethane, propane, butanes and pentane) and the relatively low temperatures of the removed nitrogen and methane are efiectively utilized for cooling purposes in the multiple stages of the cascade system of refrigeration. Another object of the invention is to provide an improved arrangement by which the relatively low temperatures of the gases evaporating from the surface of the liquefied final product in the storage holder are effectively utilized for retaining the refrigerants in two or more stages of the cascade system in liquid condition at low enough pressures for safe storage while the refrigerating compressors are shut down.

Numerous other objects, features and advantages of the system will be apparent from the following detailed description of one preferred method of and one preferred apparatus for carrying the invention into effect. In the accompanying drawings:

Figure 1 of the drawings illustrates the above described Table I, and

Figure 2 of the drawings illustrates one preferred form of the apparatus in diagrammatic form.

In the following description, we frequently refer to certain pressures and temperatures in rather specific values in order to make a complete and thorough disclosure to those skilled in the art, but we wish it to be understood that these pressures and temperatures are illustrative or preferred values and are not to be considered as limitative of the invention.

The preferred system of liquefaction herein disclosed is a cascade system wherein heat is elevated by means of mechanical power through several stagesfrom low temperatures to high temperatures. It is obvious that heat must flow from a level of 260 R, which is the temperature of liquid natural gas, to a higher temperature in the range of 80 R, which is a typical temperature obtainable with water in an ammonia condenser on a warm summer day. The system preferably employs three stages of refrigeration, designated A, B, and C in their entireties.

The first stage of refrigeration A in this cascade system is obtained by liquefying ammonia or any other refrigerant of that class by the performance of conventional refrigerating methods. As shown at the left hand side of the drawing, ammonia compressor I pumps gaseous ammonia from intake line H at approximately 18 pounds per square inch absolute pressure (hereinafter abbreviated as p. s. i. a.). The intake pressure of stage A and subsequent stages B and C are controlled at 18 p. s. i. a. for two reasons. First, to minimize the possibility of leakage in or out of stuffing boxes. Second, to strike a mean between pressures lower which would favor the refrigerating process and pressures higher which would favor compressor intake conditions. The outlet side of the ammonia compressor l0 discharges to line 12 at approximately 150 p. s. i. a., this line connecting to a conventional oil separator l3. From this oil separator a line H extends to the tubes of an ammonia condenser I5. The ammonia gas is condensed to the liquid phase in its passage through the tubes of condenser 15, and

this liquid ammonia leaves the condenser by way of line l6. Cooling water enters the chamber area around the tubes of condenser l5 through water inlet pipe I1, and this water leaves the cooling chamber through pipe'il 8. An automatic control valve I9 is interposed in the water inlet pipe H for controlling the rate of flow of the water through the condenser, this valve I9 being thermostatically controlled by having its thermally responsive bulb immersed in the ammonia outlet line !6 leading from the condensing tubes of condenser IE. The liquid ammonia i conducted through line Hi to the tubes of a subcooler 20 where the liquid ammonia is further cooled by cold gases conducted into the chamber of subcooler 20 from a subcooler cooling line 2|. This subcooler cooling line 2| receives the heavier hydrocarbons which have been condensed out of the natural gas and also receives the vent and flash gases which have been separated from the natural gas and conducts these separated constituents as a cooling medium through three subcoolers indicated at 20, 44, and 85, which are interposed in the three stages of refrigeration A, B, and C. The outlet leading from the chamber area of subcooler 20 connects through section 2 la of cooling line 2| with a governor or regulating valve 23, which in turn is connected through disposal line 24 with a disposal system where the gases are consumed ininternal combustion engines, furnaces, or otherwise disposed of in any desired manner. Referring again to the ammonia cycle of this first stage A, the liquid ammonia, and some gases, leave the tubes of the subcooler 20 by line 25 and pass to a receiver 25, where further subcooling is accomplished by cold gases which are caused to pass through subcooling tubes 26 disposed within the receiver 26. These cold gases passing through the tubes 26 are supplied through a receiver cooling line 21 which leads from the evaporating area of the storage holder, as will be hereinafter described. The discharge ends of the tubes 26- connect through section 21a of receiver cooling line 21 with waste pipe 24, which discharges to the aforementioned disposal system. Uncondensed gases collecting within the chamber space of receiver 26 may be vented therefrom through valve 28. Equalizer line 29 from receiver 26 to condenser l5 prevents gas accumulation in receiver 26 which would impede liquid flow to receiver 26. From receiver 26 the liquid ammonia flows through line 36 to a level controlled valve 3| associated with an ethylene condenser 32. The liquid ammonia enters the valve 3|- at approximately p. s. i. a., and expands through this valve down to approximately 18 p. s. i. a. This lower pressure is the pressure in the chamber area around the tubes of ethylene condenser 32, which is controlled by the pressure in line H referred to at the start of the cycle. The quantity of ammonia pumped by the compressor I0 is so adjusted that the pressure of 18 p. s. i. a. around the tubes of the ethylene condenser 32 is held constant. Thus, by well known physical-chemical laws the temperature of the evaporating ammonia around the tubes of ethylene condenser 32 is held at 21 F. The foregoing represents a closed ammonia system which constitutes the first stage of refrigeration of our system;

The second stage of refrigeration, indicated in its entirety at B, is obtained by liquefying ethylene, ethane, or other refrigerants of that class by compression and expansion steps similar to those described above in connection with the first stage A. The ethylene compressor 35 pumps a gaseous ethylene from intake line 36 at approximately 18 p. s. i. a., the compressor discharging into outlet line 31 at a pressure of approximately 367 p. s. i. a. This high pressure ethylene gas is conducted from line 31 to an after-cooler 38, and thence through line 39 to an oil separator 4|, and thence through line 42 to the tubes of the ethylene condenser 32. The ethylene gas entering the tubes of this condenser 32 at approximately 367 p. s. i. a. passes countercurrent to the ammonia gas in the condenser chamber outside the tubes. Within this condenser the ethylene gas is liquefied by means of evaporating ammonia, and the heat released from the ethylene is taken up and carried away by the ammonia. Liquid ethylene leaves the tubes of condenser 32 and flows by way of line 48 to the subcooler 44 and thence through line 45 to a receiver 46, and thence through line 48 to a level controlled valve 49. The liquid ethylene is subcooled in the subcooler 44 by the aforementioned cold gases which enter the subcooler through pipe 210 of the subcooler cooling line 2 l, these cold gases passing through the chamber area of the subcoler. From the discharge outlet of this chamber area, these cold gases are conducted through the series section 2 lb of the cooling line 2| to the inlet of subcooler 20. The liquid ethylene is also subcooled in the receiver 46 by the aforementioned cold gases which enter the receiver through pipe 210 of receiver cooling line 21, this line introducing the cold gases flowing into the tubes 46' of the receiver 46. The receiver cooling line continues by way of pipe 21b from the tubes 46' of receiver 46 to the tubes 26' of receiver 26. Uncondensed vapors may be vented from the receiver 46 by means of valve 53, which is connected through pipe 55 and cooling line section 2lb with the inlet end of the chamber area of subcooler 28.

Equalizer line 50 from receiver 46 to condenser 32 prevents gas accumulation in receiver 46 which would impede liquid flow to receiver 46.

The ethylene liquid enters the level controlled expansion valve 49 at a pressure of approximately 367 p. s. i. a. The valve 49 is responsive to liquid level in the chamber area of a methane condenser 62, and the discharge side of the valve discharges into this methane condenser at a pressure of approximately 18 p. s. i. a. The chamber area of this methane condenser 62 i connected by line 63 with the chamber area of another methane condenser 64, this latter condenser bein connected in turn to the gaseous ethylene line 36 leading to the ethylene compressor 35. The expansion pressure of approximately 18 p. s. i. a. at the outlet side of valve 49 is the pressure which prevails in the chamber areas around the tubes of the methane condensers 62 and 64, this pressure being controlled by the pressure in line 36 which was referred to above at the beginning of the description of the second stage B of refrigeration. The quantity of ethylene pumped by compressor 35 is so adjusted that the pressure of approximately 18 p. s. i. a. is maintained substantially constant around the tubes of the methane condensers 62 and 64. Thus, by well known physical-chemical laws the temperature of the evaporating ethylene is held at substantially 147 F. This latter portion of the system constitutes the closed ethylene system or the second stage of refrigeration B.

Referring now to the third stage of refrigeration, indicated in its entirety at C, this involves liquefying methane, or carbon monoxide, or other refrigerants of that class, in a manner similar to the first and second stages of refrigeration. The methane compressor 18 pumps gaseous methane from line H at approximately 18 p. s. i. a. to line 12 at a pressure of approximately 620 p. s. i. a. From line 12 this gaseous methane at high pressure passes through the after-cooler l3 and thence through line 14, oil separator 15 and line 16 to the tubes of the methane condenser 64. Within these tubes of the condenser 64 the methane gas at approximately 620 p. s. i. a. passes countercurrent to the ethylene gas flowing through the chamber area outside the tubes, and impurities which may be present in the methane stream which are more easily condensable than methane are condensed and drained oil from the tubes of, condenser 64 through line 11 leading to the heavy receiver 18. Leading from the heavy receiver 18 is a discharge line 19 which connects with cooling line section 2lc extending to the chamber area of subcooler 44. The, flow through line 19 is controlled by a level responsive valve 8| which is controlled by the level in the heavy receiver I8, the collection of the heavier impurities in this receiver 18 opening the valve 8| at a predetermined level and permitting dis- The methane gas leaving the discharge end of I the tubes of methane condenser 64 passes through line 83 to the tubes of the other methane condenser 62. The methane gas is liquefied in these tubes by evaporating ethylene in the chamber area of condenser 62 outside of the tubes. Heat released from the methane is taken up and carried away by the ethylene. Liquid methane leaves the tubes of condenser 62 and flows by way of line 84 to the tubes of a subcooler 85. From the discharge end of these subcooler tubes the liquid methane is conducted by way of line 86 to a receiver 88, and thence by way of line 89 to the level controlled valve 9 I. Within the subcooler 85, the liquid methane is subcooled by cold gases and liquids received over pipe 2Id of the subcooler cooling line 2|. The discharge from the chamber area of subcooler is through pipe 2Ic of the subcooler cooling line leading to the chamber area of subcooler 44. Uncondensed vapors may be vented from the receiver 88 by way of vent valve and line 96 which also connects with pipe 2 le leading to the subcooler 44.

The methane liquid enters the level controlled expansion valve 9 l at a pressure of approximately 620 p. s. i. a., and expands down through this valve to a pressure of approximately 18 p. s. i. a., the latter pressure being the pressure of the chamber area of the natural gas condenser 91. The valve 9i is responsive to the liquid level in this chamber area of condenser 91. This chamber area discharges through line 98 to the chamber area of another natural gas condenser 99. The chamber area of this latter condenser discharges through line H to the intake side of the methane compressor 10. The above pressure of approximately 18 p. s. i. a. which is maintained around the tubes in these natural gas condensers 91 and 99 is controlled by the pressure in this line H referred to above in the beginning of the description of this third stage. The quantity of methane pumped by the compressor 10 is so adjusted that the pressure of approximately 18 p. s. i. a. around the tubes of condensers 91 and 99 is held substantially constant. Thus, by well known physical chemical laws, the temperature of the evaporatin methane is held at approximately 256 F. This latter portion of the apparatus constitutes the closed methane system or third stage of refrigeration.

The above described liquid methane is utilized to effect the condensation of the natural gases or other hydrocrabon constituents of fuel gases by bringing about a countercurrent heat exchange between the two within the natural gas condensers 91 and 99. The natural gas is brought in from its point of supply through line I0l, from whence it enters the natural gas compressor I02 or the pressure regulating governor valve I93, by means of appropriate manipulation of valves I04 and I95 as explained below, depending upon the pressure of the gas coming through supply line IOI. If the supply pressure is substantially below 100 p. s. 1. a., then the supply gas is fed to the compressor I02 for the purpose of having its pressure raised substantially to 100 p. s. i. a. On the other hand, if the gas coming in over the supply line IOI has a pressure substantially in excess of 100 p. s. i. a., then this supply gas is passed through the pressure reducing governor I03 for reducing the pressure down to approximately 100 p. s. i. a. It will be understood that this illustrative or preferred pressure of 100 p. s. i. a. is exemplary of preferred practice according to the pres-nt invention, but is not necessarily limitative. When one or more gases of a mixture are to be separated by fractional liquefaction, it has been found that better and sharper separation may be secured at lower pressures. Less of the more volatile constituents of the mix;d gas dissolve in the liquids condensed at various stages in the cooling and therefore greater proportions of constituents more volatile than methane may be discharged at the residual vent with smaller attendant losses of the desirable hydrocarbon constituents. For instance, at pressuns of approximately 100 p. s. i. a., liquids of high purity representing butane, propane, ethane and methane may be drawn oif the various stages of the cooling chamber and stored. The lower the pressure the purer the product becomes. The regulating valve or governor I03 is connected in parallel around the compressor I02, and the gas can be caused to flow through either one of these units by appropriate manipulation of the control valves I04, I05. The gas leaves either the compressor I02 or the governor I03 and passes through line I06 to an aftercooler I01, and thence passes through line I08 to the oil separator I09. From the oil separator the gas passes through line I I I to liquid purifier I I2. This liquid type of purifier I I2 serves to remove carbon dioxide and other gases which would solidify in the natural gas condensers 91 and 99. From the purifier I I2 the gas flows via line II3 to driers H4 and H5 which are connected in parallel through suitable control valves H6. The gas is passed through these driers for the purpose of removing all water vapor therefrom which would otherwise solidify in the tubes of the natural gas .condensers 91 and 99. One drier H4 or '5 is in use while the other drier is being reconditioned for use. The gas flows from these driers over line H8 to the inside'of the tubes of the natural gas condenser 99, where most of the hydrocarbons of higher molecular weight than ethane are condensed and drained off into the receiver I2I over line I22. As these hydrocarbons collect in the receiver I.2I, they are allowed to flow from this receiver to the subcooler cooling line 2Id under the control of the level controlled valve. I23, this valve being reponsive to the level of the hydrocarbons in receiver I2I. This is the source of the hydrocarbons of higher molecular weight than ethane which are caused to flow in series through the subcoolers 85, 44 and by way of subcoolerfcooling line 2|, for the purpose of effectively utilizing the low temperatures of these r.moved hydrocarbons.

From the tubes of the condenser 99 the uncondensed portion of the natural gas stream consisting substantially entirely of methane, ethane and nitrogen, continues over line I24 to the inside of the tubes of the other natural gas condenser 91, where most of the methane and ethane and a major portion of the nitrogen are liquefied by evaporating methane from valve 9|,

' cated at I36.

10 as above described. The liquefied methane, ethane and nitrogen leave the tubes of this second condenser 91 over line I25 which extends to receiver I26. Uncondensed nitrogen and other gases are removed substantially entirely at this point, these uncondensed gases leaving the receiver I26 by way of valve I21 and line 2 le extending to subcooler cooling line 2 Id. Hence, the low temperatures of the removed nitrogen, other un condensed gases and methane are effectively utilized for subcooling purposes in the subcoolers 85, 44 and 20 of all three stagesof refrigeration. As the liquid methane, ethane and nitrogen are collected in receiver I26 they are released therefrom at substantially 100 p; s. i. a. by way of float controlled valve I29 which controls discharge line I31 and which is responsive to liquid level in the receiver I26. Discharge line I3I conducts the liquefied methane, ethane and nitrogen to flash tank I32. The uppzr area of this flash tank I32 is connected to section 2| 1 of the subcooler cooling line 2|. This pipe 2| thus connects to pipes 2 le and 2Id extending to methane subcooler and thence on through the series of subcoolers to the regulator 23 which connects with the disposal system pipe line 24. It will hence be seen that the pressure which is established by the governor 23 is transmitted back through the subcooling line 2I and establishes or controls the pressure within the flash tank I 32. Assuming that the governor 23 is set to maintain a substantially predetermined pressure of 35 p. s. i. a., this will set the temperature in the flash tank I32 at approximately minus 257 F. where nitrog-n and ethane are present in controlled quantities. Changing the pressure in flash tank I32, as by changing the setting of regulator 23, changes the chemical composition of the liquid in flash tank I32 and has a definite effect on the temperature in this flash tank, as can be readily calculated by those skilled in the art.

Gases evolved in the flash tank I32 during the expansion through valve I29 are vented through pipe 2If and pipe 2Id to the methane subcooler 85, as before described. These gases, together with the liquids transmitted down through valve I23 exchange heat with the liquid methane in the methane subcooler 85, and thereafter they proceed over subcooler cooling line 2| to the ethylene subcooler 44 and to the ammonia subcooler 20 where heat exchange takes place in each of the refrigeration stages. This cooling medium, passing through the subcooler cooling line 2|, then proceeds through governor 23 to the disposal pipe line 24. The afore-mentioned process control is obtained by giving different settings to the governor 23.

Liquefied gas, consisting substantially entirely of methane and a minor proportion of ethane and nitrogen, leaves the flash tank I32 by way of line I34 under the control of level controlled valve I35 which is responsive to liquid level within the flash tank. The liquefied gases expand through valve I35 from a pressure of approximately 35 p. s. i. a. down to a pressure of approximately 18 p. s. i. a., a pressure slightly higher than atmospheric. Gases evolved during the expansion through valve I35, together with the liquifled gases, proceed over line I34 to the insulated storage holder diagrammatically indi- The liquids remain for storage in this heavily insulated vessel while gases proceed byway of line 210 to the cooling tubes 46' of ethylene receiver 46. The line or pipe 210 is heat infiltration into the storage holder, continually produces quantities of cold methane and nitrogen gases at a temperature of approximately minus 260 F. As above stated, this gas passes through the cooling tubes of the ethylene receiver 46 and the ammonia receiver 26. The refrigeration which is thereby obtained from these low temperature gases is used to keep the operating stock of ammonia and ethylene in liquid condition at low enough pressures for safe storage while the refrigerating compressors are shut down.

With reference to the methane employed in the third stage of refrigeration C, the supply of methane for the initial starting of this stage can be obtained through valve I i! from line I I8 to line H. After a supply of liquid natural gas is established in the storage holder, a preferred supply of methane may be obtained from line 210 through line 90 and valve H and delivered to line II.

Referring now to the regasification cycle, let us assume that there has been a breakage in the main supply line leading from the gas field or other temporary failure of normal supply, and that it is desired to regasify all or part of the liquid substitute fuel in the storage holder I36. This is accomplished by drawing liquid from the holder through link I38 by means of pump I40. This pump raises the pressure on the liquid slightly higher than the gas pressure in the distribution system, such distribution system being represented by the pipe line I42. Under the higher pressure created by the pump I40 the liquid passes up into the inside of the tubes of the re-heater I44. The tubes of this re-heater or regasifier are surrounded by steam confined within an endlosing steam chest. The steam enters through a thermostatically controlled steam valve I46 which has its control bulb located in the outlet gas line I42. The condensate from the steam is removed automatically through trap valve I48 interposed in discharge line I49. Thus, the liquid gas is pumped from the storage holder I36 by pump I40 and is evaporated into the gaseous phase by the heat interchange occurring in the regasifier I44. This regasifing cycle or operation can b performed very rapidly for emergency situations.

Diluent gases required for proper utilization may be pumped into line I42 from diluent supply line I52 by means of compressor I53 via discharge line I54 and controller I55. Controller I55 may be one of several proportioning devices well known to the gas industry and is used to control the desired amount of diluent.

While we have illustrated and described what we regard to be the preferred method and the preferred apparatus for carrying our invention into effect, nevertheless it will be understood that such are merely exemplary, and that numerous modifications and rearrangements may be made therein without departing from the essence of the invention.

12 We claim: 1. In apparatus of the class described, the combination of a plurality of stages of refrigeration connected in cascade, a subcooler in each stage, means in the low temperature stage of refrigeration for removing the hydrocarbons of higher molecular weight than ethane from the natural gas by liquefaction, and means for passing these hydrocarbons of higher molecular weight than ethane back through said subcoolers in a direction from the lower temperature stage to the higher temperature stage.

2. The method of processing natural gas, consisting largely of methane and containing a substantial proportion of nitrogen and a substantial proportion'of hydrocarbons of higher molecular weight than ethane, so as to provide a body of liquefied gas consisting substantially entirely of 'a major proportion of methane and a minor proportion of ethane, said body of liquefied gas being adapted for long period storage at low temperatures and at pressures only slightly in excess of atmospheric so as to be available for use as an emergency fuel upon regasification, which method comprises, passing said natural gas through a series of progressively cooler refrigeration zones, initially liquefying all hydrocarbons of higher molecular weight than ethane in the first of said refrigeration zones, separating said initially liquefied hydrocarbons, liquefying substantially all of the methane and ethane in said uncondensed portion together with a portion of the nitrogen, separating the uncondensed nitrogen and any uncondensed methane from the liquefied mixture of methane, ethane and nitrogen, removing said liquefied nitrogen by a fiash pressure reduction, separating the regasified nitrogen from the remaining liquid, and passing said initially liquefied hydrocarbons of higher molecular weight than ethane in heat exchange relationship in a counter direction through said series of refrigerated zones.

3. The method of processing natural gas, containing at least about 80% of methane, at least about 9.5% of nitrogen, and at least about 5% of hydrocarbons of higher molecular weight than ethane, so as to provide a body of liquefied gas consisting substantially entirely of a major proportion of methane and a minor proportion of ethane, said body of liquefied gas being adapted for long period storage at low temperatures and at pressures only slightly in excess of atmospheric so as to be available for use as an emergency fuel upon regasification, which method comprises, passing said natural gas through a series of progressively cooler refrigeration zones, initially liquefying all hydrocarbons of higher molecular weight than ethane in the first of said refrigeration zones, separating said initially liquefied hydrocarbons, liquefying substantially all of the methane and ethane in said uncondensed portion together with a portion of the nitrogen, separating the uncondensed nitrogen and any uncondensed methane from the liquefied mixture of methane, ethane and nitrogen, removing said liquefied nitrogen by a flash pressure reduction, separating the regasified nitrogen from the remaining liquid, and passing said initially liquefied hydrocarbons of higher molecular weight than ethane in heat exchange relationship in a counter direction through said series of refrigerated zones.

4. In apparatus of the class described, the combination of a plurality of stages of refrigeration connected in cascade, a subcooler in each stage,

means in the low temperature stage of refrigeration for condensing hydrocarbons in the natural gas of higher molecular weight than ethane, and means for passing these hydrocarbons of higher molecular weight than ethane back through said sub-coolers in a direction from the lower temperature stage to the higher temperature stage.

PAUL L. BORN.

DANIEL V. MEILLER.

REFERENCES CITED The following references are of record in the file of this patent:

UNITED STATES PATENTS Number Name Date 668,197 Le Sueur Feb. 19, 1901 1,912,044 Schmidt May 30, 1933 1,933,641 Schmidt Nov. 7, 1933 14 Number Name Date 1,963,922 Robinson June 19, 1934 2,065,429 Clapp Dec. 22, 1936 2,082,189 Twomey June 1, 1937 2,090,163 Twomey Aug. 17, 1937 2,180,435 Schlitt Nov. 21, 1939 2,265,527 Hill Dec. 9, 1941 OTHER REFERENCES The Liquefaction and Storage of Natural Gas to Date, presented at the 30th Annual Meeting in Washington, May 12 and May 13, 1941, of the American Institute of Refrigeration. See pages 163 through 176. Pages 167, 168, 170 through 175 especially relied upon.

The Separation of Gases by Ruhemann, reprinted by the Oxford University Press in 1945. Page 253 relied upon. 

